IR 05000395/2006002
| ML061140397 | |
| Person / Time | |
|---|---|
| Site: | Summer  |
| Issue date: | 04/24/2006 |
| From: | Landis K NRC/RGN-II/DRP/RPB5 |
| To: | Archie J South Carolina Electric & Gas Co |
| References | |
| IR-06-002 | |
| Download: ML061140397 (18) | |
Text
April 24, 2006 South Carolina Electric & Gas Company ATTN: Mr. Jeffrey B. Archie Vice President, Nuclear Operations Virgil C. Summer Nuclear Station P. O. Box 88 Jenkinsville, SC 29065 SUBJECT: VIRGIL C. SUMMER NUCLEAR STATION - NRC INTEGRATED INSPECTION REPORT 05000395/2006002 AND ANNUAL ASSESSMENT
SUMMARY
Dear Mr. Archie:
On March 31, 2006, the United States Nuclear Regulatory Commission (NRC) completed an inspection at your Virgil C. Summer Nuclear Station. The enclosed integrated inspection report documents the inspection results, which were discussed on April 11, 2006, with Mr. Jeff Archie and other members of your staff.
The inspection examined activities conducted under your license as they relate to safety and compliance with the Commissions rules and regulations and with the conditions of your license.
The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. Based on the results of this inspection, no findings of significance were identified.
In accordance with 10 CFR 2.390 of the NRCs Rules of Practice, a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of NRCs document system (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
Sincerely,
/RA/
Kerry D. Landis, Chief Reactor Projects Branch 5 Division of Reactor Projects Docket No.: 50-395 License No.: NPF-12 Enclosure: NRC Integrated Inspection Report 05000395/2006002 w/Attachment: Supplemental Information cc w/encl: (See page 2)
SCE&G 2 cc w/encl:
R. J. White Nuclear Coordinator Mail Code 802 S.C. Public Service Authority Virgil C. Summer Nuclear Station Electronic Mail Distribution Kathryn M. Sutton, Esq.
Morgan, Lewis & Bockius LLP Electronic Mail Distribution Henry J. Porter, Director Div. of Radioactive Waste Mgmt.
Dept. of Health and Environmental Control Electronic Mail Distribution R. Mike Gandy Division of Radioactive Waste Mgmt.
S. C. Department of Health and Environmental Control Electronic Mail Distribution Robert G. Sweet, Manager Nuclear Licensing (Mail Code 830)
South Carolina Electric & Gas Company Virgil C. Summer Nuclear Station Electronic Mail Distribution Robert M. Fowlkes, General Manager Engineering Services South Carolina Electric & Gas Company Virgil C. Summer Nuclear Station Electronic Mail Distribution Thomas D. Gatlin, General Manager Nuclear Plant Operations (Mail Code 303)
South Carolina Electric & Gas Company Virgil C. Summer Nuclear Station Electronic Mail Distribution David A. Lavigne, General Manager Organization Development South Carolina Electric & Gas Company Vigil C. Summer Nuclear Station Electronic Mail Distribution Distribution w/encl: (See page 3)
_________________________
OFFICE RII:DRP RII:DRP RII:DRS RII:DRS RII:DRP RII:DRP RII:DRP SIGNATURE JXZ LXC per email MSL for BWM1 HJG KDL for JXZ for NAME JZeiler MCain MScott BMiller HGepford LGarner JPolickoski DATE 04/21/2006 04/20/2006 04/24/2006 04/20/2006 04/21/2006 04/24/2006 04/21/2006 E-MAIL COPY? YES NO YES NO YES NO YES NO YES NO YES NO YES NO
U. S. NUCLEAR REGULATORY COMMISSION REGION II Docket No.: 50-395 License No.: NPF-12 Report No.: 05000395/2006002 Licensee: South Carolina Electric & Gas (SCE&G) Company Facility: Virgil C. Summer Nuclear Station Location: P. O. Box 88 Jenkinsville, SC 29065 Dates: January 1, 2006 - March 31, 2006 Inspectors: J. Zeiler, Senior Resident Inspector M. Cain, Resident Inspector J. Polickoski, Acting Resident Inspector B. Miller, Reactor Inspector, RII (Sections 1R12.2)
M. Scott, Senior Reactor Inspector, RII (Sections 1R12.2)
Approved by: K. D. Landis, Chief Reactor Projects Branch 5 Division of Reactor Projects
SUMMARY OF FINDINGS IR 05000395/2006002; 01/01/2006 - 03/31/2006; Virgil C. Summer Nuclear Station; Routine Integrated Report.
The report covered a three-month period of inspection by resident inspectors and one announced inspection by regional inspectors. No findings of significance were identified by the NRC. The significance of most findings is indicated by their color (Green, White, Yellow, Red)using IMC 0609, Significance Determination Process (SDP). Findings for which the SDP does not apply may be Green or be assigned a severity level after NRC management review. The NRCs program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, Reactor Oversight Process, Revision 3, dated July 2000.
NRC-Identified and Self-Revealing Findings
No findings of significance were identified.
Licensee-Identified Violations
None.
REPORT DETAILS
Summary of Plant Status
The unit began the inspection period at 100 percent rated thermal power (RTP). The unit operated at or near full power for the entire inspection period.
REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity
1R01 Adverse Weather Protection
Unexpected Cold Weather Conditions
a. Inspection Scope
The inspectors performed a readiness inspection during the week of February 13 for unexpected cold weather conditions. The inspectors reviewed the sites preparations and evaluated the implementation of Operations Administrative Procedure (OAP)-109.1, Guidelines for Severe Weather. The inspectors walked down accessible areas of risk-significant equipment, including, but not limited to, level instrumentation associated with the refueling water storage tank and condensate storage tank, to assess whether the equipment was adequately protected from cold weather conditions. The inspectors evaluated the status of freeze protection equipment and alarms to verify there were no degradations which could challenge the capability of equipment important to plant operation or safety. Also, the inspectors reviewed the licensees corrective action program (CAP) database to verify that freeze protection problems were being identified at the appropriate level, entered into the CAP, and appropriately resolved.
b. Findings
No findings of significance were identified.
1R04 Equipment Alignment
a. Inspection Scope
The inspectors conducted three partial equipment alignment walkdowns (listed below) to evaluate the operability of selected redundant trains or backup systems with the other train or system inoperable or out-of-service (OOS). Correct alignment and operating conditions were determined from the applicable portions of drawings, system operating procedures (SOPs), Final Safety Analysis Report (FSAR), and technical specifications (TS). The inspections included review of outstanding maintenance work requests (MWRs) and related Condition Evaluation Reports (CERs) to verify that the licensee had properly identified and resolved equipment alignment problems that could impact mitigating system availability. Documents reviewed are listed in the Attachment.
- A and B service water (SW) pumps while the C SW pump was OOS for scheduled maintenance;
- A emergency diesel generator (EDG) while the B EDG was OOS for scheduled quarterly preventive maintenance; and,
- A and B motor driven emergency feedwater (MDEFW) pumps while the turbine driven emergency feedwater pump (TDEFW) was OOS for scheduled maintenance.
b. Findings
No findings of significance were identified.
1R05 Fire Protection
a. Inspection Scope
The inspectors reviewed recent CERs, MWRs, and impairments associated with the fire suppression system. The inspectors reviewed surveillance activities to determine whether they supported the operability and availability of the fire protection system. The inspectors assessed the material condition of the active and passive fire protection systems and features and observed the control of transient combustibles and ignition sources. The inspectors conducted routine inspections of the following nine areas (respective fire zones also noted):
- A and B EDG rooms (fire zones DG-1.1/1.2 and DG-2.1/2.2);
- A and B heating, ventilation, and air conditioning (HVAC) chilled water pump rooms (fire zones IB-7.2, IB-9, and IB-23.1);
- A and B component cooling water pumps/heat exchangers and service water booster pump room (fire zones IB-25.1.1, IB-1.2, IB-1.3, and IB-1.5);
- Turbine driven emergency feedwater pump room (fire zone IB-25.2);
- SW pump house (fire zones SWPH-1, SWPH-3, and SWPH-5.1/5.2);
- A and B residual heat removal and reactor building spray pump rooms (fire zones AB-1);
- Control Room (fire zone CB-17.1);
- 1DA switchgear room (fire zone IB-20); and,
- A, B, and C charging pump rooms (fire zones AB-1.5, AB-1.6, and AB-1.7).
b. Findings
No findings of significance were identified.
1R11 Licensed Operator Requalification Program
a. Inspection Scope
On March 6, 2006, the inspectors observed performance of senior reactor operators and reactor operators on the plant simulator during licensed operator requalification training.
The training scenario (LOR-SA-006) involved a dropped control rod, high main generator turbine vibration, and a control rod ejection loss-of-coolant accident. The inspectors verified that training included risk-significant operator actions and implementation of emergency classification and the emergency plan. The inspectors assessed overall crew performance, communications, oversight of supervision, and the evaluators' critique. The inspectors verified that any training issues were appropriately captured in the licensees CAP.
b. Findings
No findings of significance were identified.
1R12 Maintenance Effectiveness
.1 Routine Maintenance Effectiveness Inspection
a. Inspection Scope
The inspectors evaluated two equipment issues described in the CERs listed below to verify the licensees effectiveness of the corresponding preventive or corrective maintenance associated with structures, systems or components (SSCs). The inspectors reviewed maintenance rule (MR) implementation to verify that component and equipment failures were identified, entered, and scoped within the MR program.
Selected SSCs were reviewed to verify proper categorization and classification in accordance with 10 CFR 50.65. The inspectors examined (a)(1) corrective action plans to determine if the licensee was identifying issues related to the MR at an appropriate threshold and that corrective actions were established and effective. The inspectors review also evaluated if maintenance preventable functional failures (MPFF) or other MR findings existed that the licensee had not identified. The inspectors reviewed the licensees controlling procedures, i.e., engineering services procedure (ES)-514, Maintenance Rule Implementation, and the Virgil C. Summer Important To Maintenance Rule System Function and Performance Criteria Analysis to verify consistency with the MR requirements.
- CER 0-C-05-1341, Purge oil level switch for B HVAC chiller not functioning properly; and,
- CER 0-C-05-4573, Delta-flux for power range nuclear instrument N-43 failed to operate properly due to degraded potentiometer.
b. Findings
No findings of significance were identified.
.2 Maintenance Rule Periodic Evaluation (Triennial)
a. Inspection Scope
The inspectors reviewed the licensees Maintenance Rule periodic assessments, Maintenance Rule Fifth Periodic Assessment [Cycle 14, June 3, 2002 - November 26, 2003, dated 4/19/05] and Maintenance Rule Periodic Assessment [Cycle 15, November 26, 2003 - June 1, 2005, dated 1/9/06] while on-site the week of January 9, 2006. These reports were issued to satisfy paragraph (a)(3) of 10 CFR 50.65, and covered two 18-month periods for the single unit. The inspection was to determine the effectiveness of the assessments, that they were issued in accordance with the time requirement of the MR, and included evaluation of: balancing reliability and unavailability, (a)(1) activities, (a)(2) activities, and use of industry operating experience.
To verify compliance with 10 CFR 50.65, the inspectors reviewed selected MR activities covered by the assessment periods for the following MR a(1) status component and attendant systems: Emergency Feedwater, Building Services, Reactor Coolant, Air Handling, and Instrument Air. Specific procedures and documents reviewed are listed in the Attachment.
During the inspection, the inspectors reviewed selected plant work order data, assessments, modifications, and the site guidance implementing procedures; discussed and reviewed relevant corrective action reports, reviewed generic operations event data, attendant MR related meeting minutes, and probabilistic risk reports; and discussed issues with system engineers. Operational event information was evaluated by the inspectors in its use in MR functions. The inspectors selected work orders and other corrective action documents on systems recently removed from 10 CFR 50.65 a(1)status and those in a(2) status for the assessment periods to investigate the justification for their status (service water, control building chillers, and component cooling). The inspectors selected MR valves found in the plants emergency operating procedures (EOPs) to verify functional testing. The inspectors toured and inspected repaired components. The documents were compared to the sites MR program criteria, the MR a(1) evaluations, and MR related data bases.
b. Findings
No findings of significance were identified.
1R13 Maintenance Risk Assessments and Emergent Work Control
a. Inspection Scope
The inspectors reviewed the licensees assessments of the risk impacts of removing from service those components associated with planned and emergent work items. The inspectors evaluated the six selected work activities listed below for:
- (1) the effectiveness of the risk assessments performed before maintenance activities were conducted;
- (2) the management of risk;
- (3) that, upon identification of an unforseen situation, necessary steps were taken to plan and control the resulting emergent work activities; and
- (4) that emergent work problems were adequately identified and resolved.
The inspectors evaluated the licensees work prioritization and risk characterization to determine, as appropriate, whether necessary steps were properly planned, controlled, and executed for the planned and emergent work activities listed below:
- Work Week 2006-4, risk assessment for C SW pump and component cooling water system non-essential cross connect valves (XVB-9525A and XVB-9687A)
OOS for scheduled maintenance;
- Work Week 2006-5, risk assessment for switchyard thermography data collection, B charging pump OOS for scheduled maintenance, and emergent troubleshooting to repair intermittent steamline low pressure bistable actuation;
- Work Week 2006-6, risk assessment for B MDEFW pump, B SW pump, and main steam to A moisture separator steam pressure transmitter OOS for scheduled maintenance;
- Risk assessment for emergent work to replace B solid state protection system isolation and universal logic circuit cards due to degraded condition;
- Work Week 2006-11, risk assessment for A EDG OOS for scheduled quarterly maintenance and emergency safeguards transformer XTF-005 work; and,
- Work Week 2006-13, risk assessment for B EDG OOS for scheduled quarterly preventive maintenance and testing.
b. Findings
No findings of significance were identified.
1R15 Operability Evaluations
a. Inspection Scope
The inspectors reviewed four operability evaluations affecting risk significant mitigating systems to assess, as appropriate:
- (1) the technical adequacy of the evaluations; (2)whether operability was properly justified and the subject component or system remained available, such that no unrecognized increase in risk occurred;
- (3) whether other existing degraded conditions were considered;
- (4) where compensatory measures were involved, whether the compensatory measures were in place, would work as intended, and were appropriately controlled; and
- (5) the impact on TS limiting conditions for operations and the risk significance in accordance with the Significance Determination Process (SDP). Also, the inspectors verified that the operability evaluations were performed in accordance with station administrative procedure (SAP)-999, Corrective Action Program.
- CER 0-C-06-0406, steamline pressure low annunciation and steamline pressure channel III loop B bistable actuation;
- CER 0-C-06-0237, TDEFW discharge flow control valve (1FV-3556) indication of mid-position from Hagen controller; and,
- CER 0-C-06-0725, Excessive oil leakage from TDEFW turbine inboard bearing while operating.
b. Findings
No findings of significance were identified.
1R17 Permanent Plant Modifications
a. Inspection Scope
The inspectors evaluated an engineering change request (ECR) package for modification in the cornerstone area to evaluate the modification for adverse effects on system availability, reliability, and functional capability. The modification and the associated attributes reviewed is as follows:
ECR 50459, Replacement of Main Plant Vent Atmospheric Radiation Monitor Controls (RMA-13) and Reactor Building Purge Exhaust Atmospheric Radiation Monitor Controls (RMA-14):
- Plant Document Updating
- Post-Modification Testing
- Installation Records
- Materials / Replacement Components For the selected modification package, the inspectors observed the as-built configuration. Documents reviewed included procedures, engineering calculations, modification design and implementation packages, work orders, site drawings, corrective action documents, applicable sections of the FSAR, supporting analyses, technical specifications, and design basis information. The inspectors witnessed aspects of the post-modification testing to verify adequate testing of the new radiation monitors was implemented following installation. The inspectors also reviewed selected CERs associated with the modification to confirm that problems encountered with the implementation of the modification were entered into the CAP.
b. Findings
No findings of significance were identified.
1R19 Post-Maintenance Testing
a. Inspection Scope
For the five maintenance activities listed below, the inspectors reviewed the associated post-maintenance testing (PMT) procedures and witnessed either the testing and/or reviewed test records to assess whether:
- (1) the effect of testing on the plant had been adequately addressed by control room and/or engineering personnel;
- (2) testing was adequate for the maintenance performed;
- (3) test acceptance criteria were clear and adequately demonstrated operational readiness consistent with design and licensing basis documents;
- (4) test instrumentation had current calibrations, range, and accuracy consistent with the application;
- (5) tests were performed as written with applicable prerequisites satisfied;
- (6) jumpers installed or leads lifted were properly controlled; (7)test equipment was removed following testing; and
- (8) equipment was returned to the status required to perform its safety function. The inspectors verified that these activities were performed in accordance with general test procedure (GTP)-214, Post Maintenance Testing Guideline.
- PMT for loop B steam generator steamline pressure instrument 1PT00485 emergent repair maintenance (MWR 0601372);
- PMT for B MDEFW pump and associated room cooling fan following scheduled preventive maintenance (MWRs 0523822 and 0526179);
- PMT for TDEFW pump following scheduled preventive maintenance (MWRs 0524222, 0524260, 06014550, and 0601570); and,
b. Findings
No findings of significance were identified.
1R22 Surveillance Testing
a. Inspection Scope
The inspectors observed and/or reviewed the six surveillance tests listed below to verify that TS surveillance requirements were followed and that test acceptance criteria were properly specified to ensure that the equipment could perform its intended safety function. The inspectors verified that proper test conditions were established as specified in the procedures, that no equipment preconditioning activities occurred, and that acceptance criteria had been met.
In-Service Tests:
- Surveillance Test Procedure (STP)-223.002A, Service Water Pump Test (for B SW pump)
Reactor Coolant System Leakage Tests:
- STP-114.002, Operational Leakage Test Other Surveillance Tests:
- STP-105.016A, Train A Charging Pump and Diesel Generator Slave Relay Test;
- STP-125.002A, Diesel Generator A Operability Test;
- STP-345.074, Solid State Protection System Actuation Logic and Master Relay Test - Train B; and,
- Preventative Test Procedure (PTP)-102.001, Main Turbine Tests.
b. Findings
No findings of significance were identified.
1R23 Temporary Plant Modifications
a. Inspection Scope
The inspectors reviewed the following two plant equipment changes that were considered temporary modifications. The inspectors evaluated the change documents and the associated 10 CFR 50.59 screenings against the system design basis documentation and FSAR to verify that the changes did not adversely affect the safety function of important safety systems. In addition, the inspectors verified that the changes were developed and implemented in accordance with licensee procedures SAP-148, Temporary Bypass, Jumper, and Lifted Lead Control, and SAP-300, Conduct of Maintenance.
- Bypass Authorization Request (BAR) 06-01, bypass annunciator alarm of failed containment fire protection heat detector ITE65040; and,
- Removal and Restoration 060007, Loosening diesel generator building link seals around A SW pipe header to allow groundwater drainage.
b. Findings
No findings of significance were identified.
Cornerstone: Emergency Preparedness
1EP6 Drill Evaluation
a. Inspection Scope
On March 6, 2006, the inspectors reviewed and observed the performance of a licensee operator requalification simulator drill that involved a dropped control rod, high main generator turbine vibration, and a control rod ejection loss of coolant accident (LOR-SA-006). The inspectors assessed emergency procedure usage and verified the licensee was properly classifying emergency events and making the required notifications and protective action recommendations in accordance with emergency plan procedures (EPP)-001, Activation and Implementation of Emergency Plan, EPP-001.2, Alert, EPP-001.3, Site Area Emergency, and EPP-002, Communication and Notification.
The inspectors evaluated the adequacy of the licensees conduct of the drill and critique performance and verified that drill performance issues were captured by the licensee in their CAP.
b. Findings
No findings of significance were identified.
OTHER ACTIVITIES
4OA2 Identification and Resolution of Problems
.1 Daily Screening of Corrective Action Items
a. Inspection Scope
As required by Inspection Procedure 71152, Identification and Resolution of Problems, and in order to help identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of items entered into the licensees corrective action program. This review was accomplished by either attending daily screening meetings that briefly discussed major CERs, or accessing the licensees computerized corrective action database and reviewing each CER that was initiated.
b. Findings
No findings of significance were identified.
.2 Annual Sample Review
a. Inspection Scope
The inspectors reviewed one issue in detail to evaluate the effectiveness of the licensees corrective actions for important safety issues documented in CER 0-C-05-4111 and CER 0-C-05-4167. These CERs were associated with various equipment degradations associated with the feedwater heater drain system (i.e., solenoid valves, air operated valve positioners/actuators/regulators, and instrument air tubing) which, on one occasion, resulted in the need to downpower the unit in November 2005. The inspectors assessed whether the licensee adequately addressed all of the applicable causal factors and identified effective corrective actions. Also, the inspectors verified the issue was processed in accordance with SAP-999, Corrective Action Program.
b. Findings
No findings of significance were identified.
4OA6 Meetings, Including Exit
.1 Exit Meeting Summary
The inspectors presented the inspection results to Mr. Jeff Archie and other members of the licensee staff on April 11, 2006. The inspectors confirmed that proprietary information was not provided or examined during the inspection.
.2 Annual Assessment Meeting Summary
On March 31, 2006, the NRC Chief of Reactor Projects Branch 5 met with South Carolina Electric and Gas Company to discuss the NRCs Reactor Oversight Process (ROP) and the Virgil C. Summer Nuclear Station annual assessment of safety performance for the period of January 1, 2005 - December 31, 2005. The major topics addressed were the NRCs assessment program and the results of the Virgil C. Summer assessment. Attendees included Virgil C. Summer site management, members of site staff, and a representative of Santee Cooper.
This meeting was open to the public. The presentation material used for the discussion is available from the NRCs document system (ADAMS) as accession number ML060970298. ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
ATTACHMENT:
SUPPLEMENTAL INFORMATION
KEY POINTS OF CONTACT
Licensee
- J. Archie, Vice President, Nuclear Operations
- F. Bacon, Manager, Chemistry Services
- M. Browne, Manager, Quality Systems
- A. Cribb, Acting Supervisor, Nuclear Licensing
- M. Findlay, Manager, Nuclear Protection Services
- M. Fowlkes, General Manager, Engineering Services
- D. Gatlin, General Manager, Nuclear Plant Operations
- D. Lavigne, General Manager, Organizational Effectiveness Training
- G. Lippard, Manager, Operations
- G. Moffit, Manager, Nuclear Operations Training
- P. Mothena, Acting Manager, Health Physics and Safety Services
- J. Nesbitt, Manager, Materials and Procurement
- K. Nettles, General Manager, Nuclear Support Services
- R. Stokes, Manager, Design Engineering
- W. Stuart, Manager, Plant Support Engineering
- R. Sweet, Acting Manager, Nuclear Licensing
- A. Torres, Manager, Planning / Scheduling and Project Management
- S. Zarandi, Manager, Maintenance Services
NRC
- K. Landis, Chief, Branch 5, Division of Reactor Projects, Region II
ITEMS OPENED, CLOSED, AND DISCUSSED
Opened
None.
Closed
None.
Discussed
None.